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approach for all applications. For purpose of this study the following key assumptions were used to guide the analysis: • The system is be grid connected • The system is generally in an unattended mode of operation • The system includes thermal storage to dispatch power to the desired peak electric demand use periods • The system should minimize water requirements • The analysis should focus on the smallest possible power system size using off-the-shelf components or standard ORC technologies. Based on the key assumptions listed above, the study used the following additional guidelines to further focus the analysis: • A solar field operating temperature of 304°C was selected to allow Caloria heat transfer fluid to be used in the solar field so that a low-cost and low-risk thermal storage option would be available • The power cycle would use dry cooling to minimize water use and simplify operation • A working fluid with an above-atmospheric condenser pressure would be assumed to minimize safety concerns of potential air in-leakage to a sub-atmospheric condenser with an organic fluid • Where possible, the design should be simplified to reduce complexity and minimize O&M requirements. The detailed ORC power cycle analysis evaluated a number of potential Rankine power cycle configurations, including simple, recuperative, reheat, and reheat/recuperative Rankine cycles. Each of the cycles was optimized for use with different ORC fluids and for mixed organic working fluids. The study selected the recuperated Rankine cycle with pentane as the working fluid for the base system. Although using a reheat cycle and mixed working fluids slightly increased the cycle efficiency, these options were rejected for this study because the increased power cycle complexity and capital cost were expected to outweigh the improvements in system efficiency. A system size nominally of 1 MWe output was selected to use ORC turbine machinery, while keeping turbine speed at acceptable levels. The ORC power cycle technology required for this application is well within the capabilities of existing commercial system technology. One key issue with the system proposed, however, is the long-term stability of the pentane working fluid at the temperatures required in the power cycle. The power cycle optimization process was inherently different for a solar plant compared to geothermal power plants. For geothermal plants, the focus is typically on minimizing the power cycle capital cost. This is because the geothermal resource is relatively cheap and the resource temperatures are low. Thus, it takes a substantial capital investment to effect much change in cycle efficiency. Solar plants, on the other hand, have relatively expensive solar fuel, so the focus is on increasing power cycle efficiency to minimize solar field size. So the overall optimum plant design will favor a more efficient power cycle and a smaller solar field. The baseline solar technology evaluated in the study was the Luz System Two (LS-2) parabolic trough collector with a non-evacuated receiver. The LS-2 collector represents a good match for this type of plant, although the Industrial Solar Technology parabolic trough collector could also be used at these temperatures with a small reduction in performance, but potentially at a lower 47PDF Image | Modular Trough Power Plant Cycle and Systems Analysis
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